Prediction of Cretaceous reservoir zone through petrophysical modeling: Insights from Kadanwari gas field, Middle Indus Basin

Ali, Nafees; Chen, Jian; Fu, Xiaodong; Hussain, Wakeel; Ali, Muhammad; Hussain, Mazahir; Anees, Aqsa; Rashid, Muhammad; Thanh, Hung Vo

doi:10.1016/j.geogeo.2022.100058

Cited by 19 publications

(6 citation statements)

References 31 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Moreover, the construction of lithofacies maps (e.g., sand-ratio maps) as well as isoparametric maps are extremely recommended to examine the distribution of the sedimentary facies plus the petrophysical properties within Baltim field. Accordingly, the favorable gas zones will be accurately delineated (Anees et al 2022;Ali et al 2022).…”

Section: Discussionmentioning

confidence: 99%

The potential of offshore Nile Delta Basin natural gas reserves: a case study of Messinian reservoir in Baltim field

Sarhan

2022

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

The offshore part of the Nile Delta Basin (NDB) is a prolific provenance for gas exploration. The present study aims to perform a geophysical evaluation for the Messinian Abu Madi sandstones along the Messinian paleo-valley in Baltim field as a case study. The seismic interpretation step exposed that the Abu Madi incised valley displays NNW-SSE trend with width ranges from 5 to 8 km and a length of 32 km. The petrophysical appraisal for five drilled wells (BE-2, BE-3, BE-5, BN-1 and BN-2) in Baltim Field has been performed. The findings of this assessment revealed that the most promising intervals in the studied wells have gross-thicknesses vary between 25 and 49 m; net pay thicknesses range within 15 m and 38.5 m; net/gross ratio of 0.54–0.90; effective porosity of 15–40%; shale volume is less than 20; and water saturation ranges between 25 and 50%. Such notably talented and converging values of these parameters across the examined zones reflects the relative homogeneity and lateral continuity of the Abu Madi reservoir across the inspected paleo-valley. The results of this study can help for a better understanding of the petrophysical characteristics for the Messinian reservoir over the offshore NDB. Therefore, the Messinian sandstones could exhibit possible targets for future gas exploration over the offshore NDB together with the Pliocene sandy levels, which represent the main and the recent discoveries of gas accumulations.

show abstract

Section: Discussionmentioning

confidence: 99%

The potential of offshore Nile Delta Basin natural gas reserves: a case study of Messinian reservoir in Baltim field

Sarhan

2022

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

show abstract

“…The Lower Goru Formation was deposited over the whole basin of the Southern Indus [33,37]. The early Cretaceous Goru Formation, which is divided into two sections (the Lower Goru Formation (LGF) and Upper Goru Formation (UGF)), superimposes the Sembar Formation [44,45]. The Goru Formation was accumulated in a shallow marine environment such as a shoreface to the fluvial-based proximal delta-front depositional framework [1,41].…”

Section: General Geology and Stratigraphy Of The Study Areamentioning

confidence: 99%

Application of Machine Learning for Lithofacies Prediction and Cluster Analysis Approach to Identify Rock Type

et al. 2022

Self Cite

View full text Add to dashboard Cite

Nowadays, there are significant issues in the classification of lithofacies and the identification of rock types in particular. Zamzama gas field demonstrates the complex nature of lithofacies due to the heterogeneous nature of the reservoir formation, while it is quite challenging to identify the lithofacies. Using our machine learning approach and cluster analysis, we can not only resolve these difficulties, but also minimize their time-consuming aspects and provide an accurate result even when the user is inexperienced. To constrain accurate reservoir models, rock type identification is a critical step in reservoir characterization. Many empirical and statistical methodologies have been established based on the effect of rock type on reservoir performance. Only well-logged data are provided, and no cores are sampled. Given these circumstances, and the fact that traditional methods such as regression are intractable, we have chosen to apply three strategies: (1) using a self-organizing map (SOM) to arrange depth intervals with similar facies into clusters; (2) clustering to split various facies into specific zones; and (3) the cluster analysis technique is used to identify rock type. In the Zamzama gas field, SOM and cluster analysis techniques discovered four group of facies, each of which was internally comparable in petrophysical properties but distinct from the others. Gamma Ray (GR), Effective Porosity(eff), Permeability (Perm) and Water Saturation (Sw) are used to generate these results. The findings and behavior of four facies shows that facies-01 and facies-02 have good characteristics for acting as gas-bearing sediments, whereas facies-03 and facies-04 are non-reservoir sediments. The outcomes of this study stated that facies-01 is an excellent rock-type zone in the reservoir of the Zamzama gas field.

show abstract

“…Production from unconventional reservoirs has become a main source of hydrocarbons globally . Various factors determine oil production and commercial rates, especially for shale and tight hydrocarbon. , It is important to account for rock and fluid properties and interactions that influence oil recovery by capillary, viscous, and gravity action during well operations. Hence, understanding rock wettability is critical for formulating suitable completion fluids that improve oil recovery and for refining future enhanced oil recovery techniques. , Furthermore, oil- and mixed-oil wettabilities have been increasingly identified in tight reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Mixed Wettability Modeling and Nuclear Magnetic Resonance Characterization in Tight Sandstone

et al. 2023

View full text Add to dashboard Cite

Rock wettability significantly impacts fluid distributions in reservoirs and enhanced oil recovery. As the large variety of mixed-wet tight formations becomes increasingly evident, research evaluating wettability has become increasingly important. The nuclear magnetic resonance (NMR) technique is suitable for wettability characterization, but the simplified rock models currently used in NMR studies, that is, entirely water-wet or oilwet or classified as water-or oil-wet based on pore geometry, may result in inaccurate pore-fluid distributions and wettability estimates. In this paper, a new pore-scale mixed-wet rock model was constructed that considers the contact angle and wetting area. A tight sandstone rock saturated with oil−water is presented as an example to investigate T 2 responses and NMR T 2 -based wettability indices for different wettability features. In the model, a mixed-wet digital rock saturated with oil and water is constructed using the sedimentological process method and the Lattice Boltzmann method. Then, the random walk method is applied to simulate T 2 responses in cases with varied wettability properties, such as contact angle, wetting area ratio, and fluid saturation. Finally, the apparent contact angle cosine is used as the wettability indicator for comparison with published NMR T 2 -based wettability indices. The results showed that the combination of the wetting area ratio (determined by the pore size cutoff), actual contact angle of wetting surfaces, and fluid saturation significantly impacted T 2 distributions of fluid-saturated mixed-wet rocks. Simulations and experiments showed that three NMR T 2 -based wettability indices were inappropriate for wettability assessment in weakly wet or intermediate-wet rocks. This was because those NMR indices are based on wetting areas and do not account for the effect of local contact angles of wetting surfaces. These investigations have provided a theoretical basis for interpreting NMR T 2 characterizations in rocks with mixed wettability.

show abstract

Prediction of Cretaceous reservoir zone through petrophysical modeling: Insights from Kadanwari gas field, Middle Indus Basin

Cited by 19 publications

References 31 publications

The potential of offshore Nile Delta Basin natural gas reserves: a case study of Messinian reservoir in Baltim field

The potential of offshore Nile Delta Basin natural gas reserves: a case study of Messinian reservoir in Baltim field

Application of Machine Learning for Lithofacies Prediction and Cluster Analysis Approach to Identify Rock Type

Mixed Wettability Modeling and Nuclear Magnetic Resonance Characterization in Tight Sandstone

Contact Info

Product

Resources

About